US8657010B2 - Downhole flow device with erosion resistant and pressure assisted metal seal - Google Patents
Downhole flow device with erosion resistant and pressure assisted metal seal Download PDFInfo
- Publication number
- US8657010B2 US8657010B2 US12/912,295 US91229510A US8657010B2 US 8657010 B2 US8657010 B2 US 8657010B2 US 91229510 A US91229510 A US 91229510A US 8657010 B2 US8657010 B2 US 8657010B2
- Authority
- US
- United States
- Prior art keywords
- sleeve
- seal
- axis
- component
- disposed
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related, expires
Links
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
- E21B34/101—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for equalizing fluid pressure above and below the valve
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
- E21B2200/06—Sleeve valves
Definitions
- a downhole flow device has a sliding sleeve and a ported sleeve.
- the sliding sleeve moves hydraulically along an axis of the ported sleeve to reveal successive ports defined along the axis of the ported sleeve.
- Fluid pressure applied to an open control line enters a sealed chamber between the sliding sleeve and the housing and moves the sliding sleeve along the ported sleeve.
- a catch has a dog that engages in a slot in the sliding sleeve. As the sliding sleeve moves, the dog moves the catch with the sliding sleeve. At a pinnacle position of the catch, the sliding sleeve can no longer be moved by the hydraulic fluid due to the catch engaging a stop. When moving the catch to its stop, the sliding sleeve reveals one of the ports in the ported sleeve, allowing flow to pass through the device.
- a trigger between the sliding sleeve and housing can also move by the hydraulic pressure applied.
- This trigger moves on the sliding sleeve until it reaches another stop that limits its movement.
- the trigger moves by the bias of a spring to a reset position on the sliding sleeve.
- the trigger dislodges the catch's dog from the sleeve's slot. This allows a spring to move the catch to a next lower position where the dog can then engage in a next slot on the sliding sleeve.
- the mechanism is reset so that reapplication of hydraulic pressure can move the sliding sleeve to its next position. Applying hydraulic pressure to another port can move the sliding sleeve all the way back to its closed condition.
- a seal is provided between the sliding sleeve and the ported sleeve.
- the seal has a first seal component disposed on the sliding sleeve and has a second seal component disposed on the ported sleeve. These seal components engage one another to seal flow, and they move apart to allow fluid flow through the ports in the ported sleeve. Operation of the device and the seal reduce both erosion and damage caused by high velocity flow, abrasive flow, and differential pressures. In other words, the device and seal prevent damage to the seal when unloading a differential pressure across it, and the seal is designed in such a way that abrasive flow does not have the opportunity to impinge on the sealing surface to cause erosion.
- FIG. 1A illustrates a cross-sectional view of a downhole tool according to the present disclosure.
- FIG. 1B illustrates a detailed view of a portion of the downhole tool.
- FIG. 2 illustrates a seal of the disclosed tool in more detail.
- FIG. 3 illustrates a graph of flow passages for the seal of FIG. 2 .
- FIGS. 4A-4B show pressure assistance of the seal for the downhole tool when exposed to internal or external pressure differentials.
- FIG. 5 shows the downhole tool in a closed condition.
- FIG. 6 shows the downhole tool in a first condition towards opening.
- FIGS. 7-9 show the downhole tool in several subsequent conditions towards opening.
- FIGS. 10-14 show the downhole tool being hydraulically actuated in various stages of opening.
- a downhole flow device 100 has a housing 110 , a sliding sleeve 120 , a ported sleeve 170 , a landing 180 , and a seal 200 .
- the housing (indicated generally by 110 ) can have a number of interconnecting housing portions 110 a - f that facilitate assembly.
- the flow device 100 is a reservoir control tool that couples at uphole and downhole ends 102 / 104 to other tubing components (not shown), although the teachings of the present disclosure may be used on any other downhole flow device, such as a sliding sleeve, a downhole control valve, a crossover tool, etc.
- the tool 100 operates as a hydraulically-actuated variable choke valve and can adjust the rate of production or injection of fluid through the tool 100 .
- the tool 100 can be run as part of a completion tubing string in the well. Once deployed, operators can operate the tool 100 to variably choke back the production from the well's annulus into the tool 100 . This may be done to reduce the rate of water produced from the well or to balance the rate of production (and the rate of pressure drop) of one producing zone against another. In some cases, each production zone could have a corresponding tool 100 that can be varied. As opposed to production, the tool 100 may also be used for varied injection of fluids from the tubing string into the annulus of the well.
- the ported sleeve 170 has a plurality of ports 174 a - g disposed on an axis of the sleeve 170 . Exposure of more or less of the ports 174 a - g increases or decreases the flow through the tool 100 . Although shown having several separate ports 174 a - g, the ported sleeve 170 can have one or more ports disposed along the axis of the sleeve 174 so that more or less exposure of the one or more ports can increase or decrease flow through the tool 100 . For example, the ported sleeve 170 can having one port that increases in size along the axis of the ported sleeve 170 and can have any desirable shape.
- the sliding sleeve 120 fits all the way onto the ported sleeve 170 as shown in FIGS. 1A-1 B so that none of the ports 174 a - g in the ported sleeve 170 are exposed.
- the seal 200 on the closed sleeves 120 / 170 seals flow into (or out of) the tool 100 when the sliding sleeve 120 is in a closed position on the ported sleeve 170 .
- the tool's sliding sleeve 120 can be hydraulically moved relative to the ported sleeve 170 , and the changing position of the sliding sleeve 120 controls the flow into (or out of) the sleeve's bore 172 by disengaging the seal 200 and exposing more or less ports 174 in the ported sleeve 170 .
- the seal 200 separates, and the sliding sleeve 120 opens relative to the ports 174 to allow fluid to flow from a surrounding annulus through windows 106 in the tool's housing 110 (i.e., portion 110 e ) and into the ported sleeve's bore 172 (or vice versa).
- the ports 174 a - g defined in the ported sleeve 170 generally increase in size (diameter) along the axis of the sleeve 170 .
- the first ports 174 a (four of which are defined around the circumference of the ported sleeve 170 ) have a first diameter, while the other ports 174 b - e above them have a slightly greater diameter.
- the next highest port 174 f has an even greater diameter, and the last port 174 g has the largest diameter.
- the sliding sleeve 120 moves along the ported sleeve 170 , the sliding sleeve 120 successively reveals more of the ports 174 a - g , which increases the flow through the tool 100 .
- the tool 100 can operate at eight discrete positions to control the amount of flow area through the tool 100 . These positions are defined in percentages of the flow area of the tubing string (specifically the diameter of the ported sleeve's bore 172 ). For example, the tool's positions can be defined as follows: 0% closed, 1% open, 3% open, 5% open, 7% open, 9% open, 15% open, and 100% open. Therefore, with the tool 100 set at the 5% position, the ports 174 a - c are exposed, and the flow area through the tool 100 is 5% of the flow area through comparably sized tubing. As will be appreciated, these values are illustrative.
- the actual size and number of ports 174 a - g for an implementation depends on the overall size of the tool 100 and the desired or expected flow characteristics as well as other implementation specific details. In other examples, the tool 100 may have more or less ports, and some or all of the ports may have the same diameters.
- the seal 200 has first and second seal components 210 / 250 that mate with one another when the sliding sleeve 120 is closed.
- the first (moving) component 210 moves with the sliding sleeve 210
- the second (stationary) component 250 remains stationary.
- Either one or both of these components 210 / 250 can be incorporated into its respective sleeve (as is the stationary component 250 ) or can be an independent component affixed onto its respective sleeve (as is the movable component 210 ).
- the seal components 210 / 250 are intended to reduce damage to the seal 200 , and the design of the seal 200 is such that it resists erosion and is self-protecting.
- the moving component 210 has a first inner shelf 212 , a first inner ledge 214 , a second inner shelf 216 , and a second inner ledge 218 —each of which face inward toward the ported sleeve (not shown).
- the stationary component 250 has a somewhat complimentary configuration, including a first outer shelf 252 , a first outer ledge 254 , a second outer shelf 256 , and a second outer ledge 258 —each of which face outward from the ported sleeve (not shown).
- the stationary component 250 may also define a well 255 where the second outer shelf 256 mates with the first outer ledge 254 .
- the shelves 212 / 252 define a first flow passage 202
- the first ledges 214 / 254 define a second flow passage 204
- the second shelves 216 / 256 define a third flow passage 206 through which fluid can flow through the seal 200 .
- the flow passages 202 , 204 , and 206 create seal points between the metal-to-metal seal produced between the components 210 / 250 .
- Engagement between the first ledges 214 / 254 produces the primary sealing function when the components 210 / 250 are closed against one another.
- seal 200 achieves pressure assisted and erosion resistant sealing on the tool 100 .
- the seal 200 is assisted closed in metal-to-metal engagement by either internal pressure acting inside the tool 100 or by external pressure acting outside the tool 100 .
- FIGS. 4A-4B the tool 100 is shown closed, and the seal components 210 / 250 are shown mated with one another.
- a lower packing element or seal 178 seals between the ported sleeve 170 and the housing 110 (i.e., portion 110 f ) and isolates fluid pressure inside the tool 100 from outside the tool 100 .
- the primary sealing function of the closed seal 200 is provided by engagement of ledges 214 / 254 .
- the engagement 214 / 254 are set at a circumference that matches a centerline circumference of the lower packing seal 178 on the tool 100 .
- the arrangement of the ledges 214 / 254 , centerline, the packing seal 178 , and other features give pressure assistance to the seal 200 regardless of whether the tool 100 is exposed to internal or external pressure differentials.
- FIG. 4A an internal pressure differential in the bore 112 is shown acting on the tool 100 .
- Fluid pressure is capable of acting against the distal end of the ported sleeve 120 , which is exposed and unsealed relative to the fluid pressure in the bore 112 .
- the fluid pressure can act against the lower shoulder of the packing seal 178 .
- This fluid pressure creates a piston effect on the ported sleeve 170 .
- the resulting pressure pushes the ported sleeve 170 and its seal component 250 toward the sliding sleeve 120 and its seal component 210 , thereby assisting the sealing engagement between them.
- FIG. 4B an external pressure differential is shown acting on the tool 100 , but the seal 200 is also pressure assisted in this circumstance.
- the external fluid pressure acts against the upper shoulder of the packing seal 178 .
- This moves the packing seal 178 away from the ported sleeve's adjacent shoulder so that the seal 178 abuts a landing 180 unconnected to the ported sleeve 170 .
- the fluid pressure can act against the ported sleeve's shoulder. Again, this tends to create a piston effect on the ported sleeve 170 that attempts to push the ported sleeve 170 and its seal component 250 toward the sliding sleeve 120 and its seal component 210 . Therefore, the seal 200 and configuration of the ledges 214 / 254 and seal 178 help pressure assist the seal produced regardless of whether exposed to an internal or external pressure differential.
- the seal 200 of the present disclosure is intended to control the velocities of abrasive flow and isolates portion of the seal 200 from the flow as much as possible to mitigate erosive damage.
- the first flow passage 202 from the shelves 212 / 252 creates a very small choke when the components 210 / 250 are closed or slightly open.
- the second shelves 216 / 256 providing the second flow passage 206 also provide a secondary choke that reduces the flow possible through the seal components 210 / 250 .
- the first flow passage 202 allows fluid to flow through the seal 200 , but the small gap between the shelves 212 / 252 defines the smallest available flow area through the seal 200 .
- This secondary choke from the sealing ledges 214 / 254 also limits the detrimental flow when the seal components 210 / 250 are first separated.
- the limited flow area through the first flow passage 202 means that any sudden erosive flow from fluids flowing from the annulus into the tool (or vice versa) mainly interacts with the shelves 212 / 252 . Accordingly, the shelves 212 / 252 take the brunt of the erosive flow rather than the sealing ledges 214 / 254 themselves, which are susceptible to detrimental erosion. In this way, the seal 200 can be self-protecting by making erosion occur away from the sealing ledges 214 / 254 at initial opening of the seal 200 .
- FIG. 3 which graphs some calculations for a tool 100 having an internal diameter of about 5-in.
- the first flow passage 202 defines a limiting flow area through the tool 100 as the seal 200 is initially opened (i.e., when the sleeve 120 has traveled from 0 to 1-in.).
- the sliding sleeve ( 120 ) travels approximately 0.5-in. open from the ported sleeve ( 170 ) to expose the first port ( 174 a ) and allow 1% of flow through the tool 100 .
- the shelves 212 / 252 act to choke the flow and take the brunt of any erosive flow until the valve is 1% open.
- the first inner ledge 214 is already moved clear of the first port ( 174 a ) so the ledge 214 can avoid erosive flow, as detailed below.
- FIGS. 5-9 show some initial conditions of the seal 200 as the tool 100 opens (or closes in the reverse).
- the flow area is zero, and the sliding sleeve 120 has not moved.
- the flow passages 202 , 206 may allow for some amount of flow, the second flow passage 204 closes off the seal 200 when the ledges 214 / 254 are engaged.
- the sliding sleeve 120 As the sliding sleeve 120 continues to open, it reaches a first equalizing condition shown in FIG. 7 when the sleeve 120 travels from 0.00-in. to about 0.125-in.
- the ledges 214 / 254 move apart.
- the length and diametric gap of the ledges 214 / 254 provides for an orifice effect of any flow through the seal 200 . This helps to protect the metal seal surfaces during initial unloading of pressure and flow as described previously.
- the timing of this orifice effect is minimal as it is needed only during the first movement of separation of the two seal components 210 / 250 .
- the flow passage 202 See also, FIG. 2 ) from the shelves 212 / 252 act to choke the flow, thereby limiting the actual flow that travels through the seal 200 .
- the first flow passage 202 from the first shelves 212 / 252 is extended in comparison to the others so that these shelves 212 / 252 can define a sacrificial component during initial unloading of pressure.
- the external extension from the first flow passage 202 maintains a tight clearance and creates an orifice effect of any flow therethrough.
- the sealing shelves 212 / 252 move further apart, the volume and area increases between the two seal components 210 / 250 , thus causing a low pressure area and a drop in flow to develop.
- the choke effect from the shelves 212 / 252 continues until the moving component 210 has moved until its distal ledge 211 reaches the end of the first outer shelf 252 as shown in FIG. 8 . Beyond this position, the seal 200 reaches a second equalizing condition when the distal ledge 211 comes to separate from the ledge 254 .
- the first inner ledge 214 has preferably already passed free of the first ports 174 a in the ported sleeve 170 . Therefore, erosive damage to the ledge 214 used for closed sealing can be reduced.
- the shelves 212 / 252 and the distal ledge 211 although they may be subject to more of the erosive flow, are more suited places for such damage to occur. Once the two sealing shelves 212 / 252 slide far enough apart, the movable component 210 becomes disengaged, allowing full flow into the flow port 172 a.
- the tool has eight discrete positions in which the sliding sleeve 120 can reveal ports 174 on the ported sleeve 170 to control flow between 0%, 1%, 3%, 5%, 7%, 9%, 15%, and 100%. Details on how the sliding sleeve 120 is moved relative to the ported sleeve 170 are discussed below.
- the sliding sleeve 120 is moved relative to the ported sleeve 170 .
- the sliding sleeve 120 can be moved by any of the techniques conventionally used in the art for a flow device.
- the sliding sleeve 120 can be moved manually using an appropriate pulling tool, hydraulically by a piston arrangement, or other suitable mechanism.
- the disclose tool 100 uses a hydraulically actuated ratcheting motion to move the sliding sleeve 120 relative to the ported sleeve 170 . Details of how the tool 100 operates hydraulically are provided in FIGS. 10-14 .
- FIG. 10 portion of the tool 100 is shown in its closed condition so that the sliding sleeve 120 engages the ported sleeve (not shown) with the sealing arrangement as discussed previously.
- two control lines 103 a - b connect to hydraulic connections 130 (only one shown) on the tool 100 .
- Control fluid in the control lines 103 a - b hydraulically move the sliding sleeve 120 relative to the ported sleeve ( 170 ).
- These control lines 103 a - b run from surface equipment down the tubing string to the tool 100 .
- pressure from the open control line 130 a enters an open port 135 in the housing 110 (i.e., portion 110 b ) and travels to an outlet at a first chamber 132 between the sliding sleeve 120 and the housing portion 110 b .
- the first chamber 132 is formed by upper and lower seals 123 a - b between the sliding sleeve 120 and housing portions 110 a - b . Fluid pressure fills this first chamber 132 and acts against a shoulder at upper seal 123 b to force the sliding sleeve 120 upward in the housing 110 (i.e., the sleeve 120 moves to the left in FIG. 10 ).
- fluid pressure from the open port 135 fills a second chamber 134 at another of the port's outlets. Fluid pressure fills this second chamber 134 and acts against a trigger or unlocking sleeve 140 disposed on the sliding sleeve 120 .
- This unlocking sleeve 140 having a shape of a sleeve seals against the housing portions 110 b - c with upper and lower seals 143 a - b .
- the fluid pressure moves the unlocking sleeve 140 upward in the housing 110 along the sliding sleeve 120 (i.e., to the left in FIG. 10 ). When moved, the unlocking sleeve 140 acts against the bias of a spring 124 .
- a catch 150 having dogs 155 is also disposed on the sleeve 120 .
- This catch 150 has the shape of a sleeve and has windows for the dogs 155 .
- the catch 150 remains in position relative to the housing 110 due to the bias of another spring 126 .
- the sliding sleeve 120 moves a certain distance so that the dogs 155 in the catch 150 engage a shoulder of the first slot 125 a in the sliding sleeve 120 , as shown in FIG. 11 .
- the sliding sleeve 120 has opened to its first position (i.e., 1% open) to expose the first ports ( 174 a ) on the ported sleeve ( 170 ) (See FIG. 9 ).
- the mechanism is reset. To do this, fluid pressure at the open control line 103 a is released.
- the trigger 150 is now freed from upward pressure, and the spring 124 biases the trigger or unlocking sleeve 140 downward (i.e., to the right in FIG. 12 ).
- the end of the unlocking sleeve 140 engages the dogs 155 , freeing them from the slot 125 a as shown in FIG. 13 .
- a pair of C-rings 128 a - b help to hold the sliding sleeve 120 when positioned at varying stages along the ported sleeve 170 .
- a larger C-ring 128 b engages a circumferential groove in the housing portion 110 d to hold the sliding sleeve 120 when in the closed position.
- the smaller C-ring 128 a engages in a series of smaller circumferential grooves 115 in the housing portion 110 d as the sliding sleeve 120 is moved in stages along the ported sleeve 170 .
- the unlocking sleeve 140 engaging the dogs 155 and moved by the spring 124 frees the dogs 155 from the slot 125 a . This allows the catch 150 to reset. As shown in FIG. 14 , the spring 126 pushes the freed catch 150 downward until the dogs 155 engage in the next circumferential slot 125 b on the sliding sleeve 120 .
- the sliding sleeve 120 can be fully closed on the ported sleeve ( 170 ) to stop flow.
- the close control line 103 b connects by another port 137 to a chamber.
- the chamber is formed by upper seal 123 a between the sliding sleeve 120 and housing portion 110 a and by lower seal ( 123 c; FIGS. 1A & 9 ) between the sleeve 120 and housing portion 110 d.
- the dogs 155 with their angled edges simply ratchet past the various slots 125 along the sleeve 120 as the sleeve 120 can return to its closed position.
- the C-rings 128 a - b shown in FIG. 1A also ride along the respective grooves 115 in the housing 110 until the larger C-ring 128 b engages in the lowest groove when the sleeve 120 has fully closed.
- the tool 100 can then be opened by applying pressure to the open control line 103 a according to the previous procedures.
- applying pressure to the close line 103 b closes the tool 100 all the way no matter what current position the sliding sleeve 120 has.
- closing at discrete positions may be desired.
- an entire reverse assembly of a catch, trigger, dogs, chambers, and slots can be provided on the tool 100 opposite to those already shown.
- these reverse components can operate in the same manner described above, but only in the reverse direction. In this way, the sliding sleeve 120 can ratchet closed in discrete positions.
- the reverse (downward) components must accommodate the upward movement of the sliding sleeve 120 from the (upward) components (i.e., catch, trigger, dogs, etc. described previously) and vice versa.
Abstract
Description
Claims (34)
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/912,295 US8657010B2 (en) | 2010-10-26 | 2010-10-26 | Downhole flow device with erosion resistant and pressure assisted metal seal |
AU2010243081A AU2010243081B2 (en) | 2010-10-26 | 2010-11-18 | Downhole flow device with erosion resistant and pressure assisted metal seal |
CA2721545A CA2721545C (en) | 2010-10-26 | 2010-11-18 | Downhole flow device with erosion resistant and pressure assisted metal seal |
EP10192151.8A EP2447466B1 (en) | 2010-10-26 | 2010-11-23 | Downhole flow device with erosion resistant and pressure assisted metal seal |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/912,295 US8657010B2 (en) | 2010-10-26 | 2010-10-26 | Downhole flow device with erosion resistant and pressure assisted metal seal |
Publications (2)
Publication Number | Publication Date |
---|---|
US20120097386A1 US20120097386A1 (en) | 2012-04-26 |
US8657010B2 true US8657010B2 (en) | 2014-02-25 |
Family
ID=43567648
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US12/912,295 Expired - Fee Related US8657010B2 (en) | 2010-10-26 | 2010-10-26 | Downhole flow device with erosion resistant and pressure assisted metal seal |
Country Status (4)
Country | Link |
---|---|
US (1) | US8657010B2 (en) |
EP (1) | EP2447466B1 (en) |
AU (1) | AU2010243081B2 (en) |
CA (1) | CA2721545C (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10597977B2 (en) | 2015-09-29 | 2020-03-24 | Halliburton Energy Services, Inc. | Closing sleeve assembly with ported sleeve |
Families Citing this family (10)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
NO20130583A1 (en) | 2013-04-29 | 2014-10-30 | Typhonix As | Separation-friendly pressure reducing device |
US9488039B2 (en) * | 2014-07-03 | 2016-11-08 | Baker Hughes Incorporated | Multi-zone single treatment gravel pack system |
CN104847301B (en) * | 2015-04-28 | 2017-12-05 | 中国石油天然气股份有限公司 | Open hole packer |
CA2983787A1 (en) | 2015-05-01 | 2016-11-10 | Churchill Drilling Tools Limited | Downhole sealing |
BR122021000433B1 (en) * | 2015-09-29 | 2022-08-02 | Halliburton Energy Services, Inc | WELL SYSTEM |
US20180328496A1 (en) * | 2017-05-10 | 2018-11-15 | Baker Hughes Incorporated | Flow diffuser valve and system |
US10502023B2 (en) * | 2017-10-12 | 2019-12-10 | Baker Hughes, A Ge Company, Llc | Valve arrangement, system and method |
US11286749B2 (en) * | 2018-05-22 | 2022-03-29 | Halliburton Energy Services, Inc. | Remote-open device for well operation |
US11668163B2 (en) | 2020-12-30 | 2023-06-06 | Halliburton Energy Services, Inc. | Multilateral junction having expanding metal sealed and anchored joints |
AU2020483809A1 (en) * | 2020-12-30 | 2023-03-02 | Halliburton Energy Services, Inc. | Interval control valve including an expanding metal sealed and anchored joints |
Citations (68)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2317021A (en) | 1940-02-05 | 1943-04-20 | Bassinger Ross | By-pass and releasing means |
US2853265A (en) | 1955-08-12 | 1958-09-23 | Baker Oil Tools Inc | Telescopic valve apparatus for testing well bore tubing |
US2888080A (en) | 1957-12-13 | 1959-05-26 | Jersey Prod Res Co | Permanent well completion apparatus |
US3051243A (en) | 1958-12-12 | 1962-08-28 | George G Grimmer | Well tools |
US3071193A (en) | 1960-06-02 | 1963-01-01 | Camco Inc | Well tubing sliding sleeve valve |
US3151681A (en) | 1960-08-08 | 1964-10-06 | Cicero C Brown | Sleeve valve for well pipes |
US3355142A (en) | 1964-09-29 | 1967-11-28 | Baker Oil Tools Inc | Sleeve or piston type valve device |
US3395758A (en) | 1964-05-27 | 1968-08-06 | Otis Eng Co | Lateral flow duct and flow control device for wells |
US3414060A (en) | 1967-11-20 | 1968-12-03 | Joseph T. Zak | Selective shifting tool |
US3773441A (en) | 1971-05-19 | 1973-11-20 | A Schertz | Combination sand bailer and fluid pump with automatic grit separator and lubricator |
US4134454A (en) * | 1977-09-21 | 1979-01-16 | Otis Engineering Corporation | Multi-stage sliding valve fluid operated and pressure balanced |
US4270610A (en) * | 1980-01-15 | 1981-06-02 | Halliburton Company | Annulus pressure operated closure valve with improved power mandrel |
US4532987A (en) | 1984-02-21 | 1985-08-06 | Reed Lehman T | Geothermal expansion spool piston |
US4633952A (en) * | 1984-04-03 | 1987-01-06 | Halliburton Company | Multi-mode testing tool and method of use |
US4971099A (en) | 1989-12-15 | 1990-11-20 | Cooper Industries, Inc. | Pressure balanced cartridge choke valve |
US5156220A (en) | 1990-08-27 | 1992-10-20 | Baker Hughes Incorporated | Well tool with sealing means |
US5263683A (en) | 1992-05-05 | 1993-11-23 | Grace Energy Corporation | Sliding sleeve valve |
US5299640A (en) | 1992-10-19 | 1994-04-05 | Halliburton Company | Knife gate valve stage cementer |
US5364110A (en) | 1992-12-11 | 1994-11-15 | Halliburton Company | Downhole tool metal-to-metal seal |
US5443129A (en) | 1994-07-22 | 1995-08-22 | Smith International, Inc. | Apparatus and method for orienting and setting a hydraulically-actuatable tool in a borehole |
US5611547A (en) | 1993-11-04 | 1997-03-18 | Baker Hughes Incorporated | Elongated seal assembly for sealing well tubing-to liner annulus |
US5718289A (en) | 1996-03-05 | 1998-02-17 | Halliburton Energy Services, Inc. | Apparatus and method for use in injecting fluids in a well |
EP0893575A2 (en) | 1997-07-21 | 1999-01-27 | Halliburton Energy Services, Inc. | Flow control apparatus for use in a subterranean well and associated methods |
US5896928A (en) | 1996-07-01 | 1999-04-27 | Baker Hughes Incorporated | Flow restriction device for use in producing wells |
US5906238A (en) | 1996-04-01 | 1999-05-25 | Baker Hughes Incorporated | Downhole flow control devices |
US5957207A (en) | 1997-07-21 | 1999-09-28 | Halliburton Energy Services, Inc. | Flow control apparatus for use in a subterranean well and associated methods |
US5979558A (en) | 1997-07-21 | 1999-11-09 | Bouldin; Brett Wayne | Variable choke for use in a subterranean well |
US6041857A (en) | 1997-02-14 | 2000-03-28 | Baker Hughes Incorporated | Motor drive actuator for downhole flow control devices |
US6044908A (en) | 1998-05-29 | 2000-04-04 | Grant Prideco, Inc. | Sliding sleeve valve and seal ring for use therein |
US6070670A (en) | 1997-05-01 | 2000-06-06 | Weatherford/Lamb, Inc. | Movement control system for wellbore apparatus and method of controlling a wellbore tool |
US6112816A (en) | 1997-07-10 | 2000-09-05 | Camco International Inc. | Single-phase annulus-operated sliding sleeve |
WO2000075484A1 (en) | 1999-06-03 | 2000-12-14 | Schlumberger Technology Corporation | Apparatus and method for controlling fluid flow in a wellbore |
WO2000079094A1 (en) | 1999-06-24 | 2000-12-28 | Baker Hughes Incorporated | Variable downhole choke |
US6189619B1 (en) | 1999-06-07 | 2001-02-20 | Mark L. Wyatt | Sliding sleeve assembly for subsurface flow control |
WO2001021935A1 (en) | 1999-09-24 | 2001-03-29 | Schlumberger Technology Corporation | Valve for use in wells |
US6253850B1 (en) | 1999-02-24 | 2001-07-03 | Shell Oil Company | Selective zonal isolation within a slotted liner |
US6276458B1 (en) | 1999-02-01 | 2001-08-21 | Schlumberger Technology Corporation | Apparatus and method for controlling fluid flow |
US6293344B1 (en) | 1998-07-29 | 2001-09-25 | Schlumberger Technology Corporation | Retainer valve |
US6308783B2 (en) | 1996-04-26 | 2001-10-30 | Schlumberger Technology Corporation | Wellbore flow control device |
US6318729B1 (en) | 2000-01-21 | 2001-11-20 | Greene, Tweed Of Delaware, Inc. | Seal assembly with thermal expansion restricter |
US6328112B1 (en) | 1999-02-01 | 2001-12-11 | Schlumberger Technology Corp | Valves for use in wells |
US6328729B1 (en) | 1999-04-27 | 2001-12-11 | General Surgical Innovations, Inc. | Colporrhaphy method and apparatus |
US6338385B1 (en) | 1999-04-16 | 2002-01-15 | Hydril Company | Retrievable downhole adjustable choke |
WO2002016730A1 (en) | 2000-08-17 | 2002-02-28 | Abb Offshore Systems Limited | Flow control device |
US6422317B1 (en) | 2000-09-05 | 2002-07-23 | Halliburton Energy Services, Inc. | Flow control apparatus and method for use of the same |
US6434651B1 (en) | 1999-03-01 | 2002-08-13 | Sun Microsystems, Inc. | Method and apparatus for suppressing interrupts in a high-speed network environment |
US6446729B1 (en) | 1999-10-18 | 2002-09-10 | Schlumberger Technology Corporation | Sand control method and apparatus |
US6450225B2 (en) | 1999-12-22 | 2002-09-17 | Sumitomo Rubber Industries, Ltd. | Noise damper for pneumatic tire |
US6513599B1 (en) | 1999-08-09 | 2003-02-04 | Schlumberger Technology Corporation | Thru-tubing sand control method and apparatus |
US6516888B1 (en) | 1998-06-05 | 2003-02-11 | Triangle Equipment As | Device and method for regulating fluid flow in a well |
US20030056951A1 (en) | 2001-09-24 | 2003-03-27 | Frank Kaszuba | Sliding sleeve valve |
US6575243B2 (en) | 2001-04-16 | 2003-06-10 | Schlumberger Technology Corporation | Zonal isolation tool with same trip pressure test |
US20030159832A1 (en) | 2002-02-25 | 2003-08-28 | Williamson Jimmie Robert | Infinitely variable control valve apparatus and method |
US20040041120A1 (en) | 2000-12-04 | 2004-03-04 | Haughom Per Olav | Sleeve valve for controlling fluid flow between a hydrocarbon reservoir and tubing in a well and method for the assembly of a sleeve valve |
US6715557B2 (en) | 2001-03-14 | 2004-04-06 | Schlumberger Technology Corporation | Tool string |
US6722439B2 (en) | 2002-03-26 | 2004-04-20 | Baker Hughes Incorporated | Multi-positioned sliding sleeve valve |
US20040129431A1 (en) | 2003-01-02 | 2004-07-08 | Stephen Jackson | Multi-pressure regulating valve system for expander |
US6860330B2 (en) | 2002-12-17 | 2005-03-01 | Weatherford/Lamb Inc. | Choke valve assembly for downhole flow control |
US6869063B2 (en) | 2000-04-28 | 2005-03-22 | Triangle Equipment As | Sleeve valve and method for its assembly |
US6880638B2 (en) | 2000-12-04 | 2005-04-19 | Triangle Equipment Ag | Device for an opening in an outer sleeve of a sleeve valve and a method for the assembly of a sleeve valve |
US20050263279A1 (en) | 2004-06-01 | 2005-12-01 | Baker Hughes Incorporated | Pressure monitoring of control lines for tool position feedback |
WO2006120466A2 (en) | 2005-05-13 | 2006-11-16 | Petrowell Limited | Apparatus for controlling a downhole device |
US7258323B2 (en) | 2005-06-15 | 2007-08-21 | Schlumberger Technology Corporation | Variable radial flow rate control system |
US7363981B2 (en) | 2003-12-30 | 2008-04-29 | Weatherford/Lamb, Inc. | Seal stack for sliding sleeve |
US7377327B2 (en) | 2005-07-14 | 2008-05-27 | Weatherford/Lamb, Inc. | Variable choke valve |
US20090159290A1 (en) | 2007-12-19 | 2009-06-25 | Lauderdale Donald P | Controller for a Hydraulically Operated Downhole Tool |
US20090277642A1 (en) | 2006-08-03 | 2009-11-12 | Welldynamics, Inc | Metal to metal seal for downhole tools |
US7823633B2 (en) * | 2007-10-09 | 2010-11-02 | Mark David Hartwell | Valve apparatus |
Family Cites Families (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2344364B (en) * | 1998-11-20 | 2003-07-09 | Klaas Johannes Zwart | Flow control device |
GB0822144D0 (en) * | 2008-12-04 | 2009-01-14 | Petrowell Ltd | Flow control device |
-
2010
- 2010-10-26 US US12/912,295 patent/US8657010B2/en not_active Expired - Fee Related
- 2010-11-18 CA CA2721545A patent/CA2721545C/en not_active Expired - Fee Related
- 2010-11-18 AU AU2010243081A patent/AU2010243081B2/en not_active Ceased
- 2010-11-23 EP EP10192151.8A patent/EP2447466B1/en not_active Not-in-force
Patent Citations (83)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2317021A (en) | 1940-02-05 | 1943-04-20 | Bassinger Ross | By-pass and releasing means |
US2853265A (en) | 1955-08-12 | 1958-09-23 | Baker Oil Tools Inc | Telescopic valve apparatus for testing well bore tubing |
US2888080A (en) | 1957-12-13 | 1959-05-26 | Jersey Prod Res Co | Permanent well completion apparatus |
US3051243A (en) | 1958-12-12 | 1962-08-28 | George G Grimmer | Well tools |
US3071193A (en) | 1960-06-02 | 1963-01-01 | Camco Inc | Well tubing sliding sleeve valve |
US3151681A (en) | 1960-08-08 | 1964-10-06 | Cicero C Brown | Sleeve valve for well pipes |
US3395758A (en) | 1964-05-27 | 1968-08-06 | Otis Eng Co | Lateral flow duct and flow control device for wells |
US3355142A (en) | 1964-09-29 | 1967-11-28 | Baker Oil Tools Inc | Sleeve or piston type valve device |
US3414060A (en) | 1967-11-20 | 1968-12-03 | Joseph T. Zak | Selective shifting tool |
US3773441A (en) | 1971-05-19 | 1973-11-20 | A Schertz | Combination sand bailer and fluid pump with automatic grit separator and lubricator |
US4134454A (en) * | 1977-09-21 | 1979-01-16 | Otis Engineering Corporation | Multi-stage sliding valve fluid operated and pressure balanced |
US4270610A (en) * | 1980-01-15 | 1981-06-02 | Halliburton Company | Annulus pressure operated closure valve with improved power mandrel |
US4532987A (en) | 1984-02-21 | 1985-08-06 | Reed Lehman T | Geothermal expansion spool piston |
US4633952A (en) * | 1984-04-03 | 1987-01-06 | Halliburton Company | Multi-mode testing tool and method of use |
US4971099A (en) | 1989-12-15 | 1990-11-20 | Cooper Industries, Inc. | Pressure balanced cartridge choke valve |
US5156220A (en) | 1990-08-27 | 1992-10-20 | Baker Hughes Incorporated | Well tool with sealing means |
US5309993A (en) | 1990-08-27 | 1994-05-10 | Baker Hughes Incorporated | Chevron seal for a well tool |
US5316084A (en) | 1990-08-27 | 1994-05-31 | Baker Hughes Incorporated | Well tool with sealing means |
US5263683A (en) | 1992-05-05 | 1993-11-23 | Grace Energy Corporation | Sliding sleeve valve |
US5299640A (en) | 1992-10-19 | 1994-04-05 | Halliburton Company | Knife gate valve stage cementer |
US5364110A (en) | 1992-12-11 | 1994-11-15 | Halliburton Company | Downhole tool metal-to-metal seal |
US5611547A (en) | 1993-11-04 | 1997-03-18 | Baker Hughes Incorporated | Elongated seal assembly for sealing well tubing-to liner annulus |
US5443129A (en) | 1994-07-22 | 1995-08-22 | Smith International, Inc. | Apparatus and method for orienting and setting a hydraulically-actuatable tool in a borehole |
US5718289A (en) | 1996-03-05 | 1998-02-17 | Halliburton Energy Services, Inc. | Apparatus and method for use in injecting fluids in a well |
US6484800B2 (en) | 1996-04-01 | 2002-11-26 | Baker Hughes Incorporated | Downhole flow control devices |
US5906238A (en) | 1996-04-01 | 1999-05-25 | Baker Hughes Incorporated | Downhole flow control devices |
US6260616B1 (en) | 1996-04-01 | 2001-07-17 | Baker Hughes Incorporated | Downhole flow control devices |
US6334486B1 (en) | 1996-04-01 | 2002-01-01 | Baker Hughes Incorporated | Downhole flow control devices |
US6612547B2 (en) | 1996-04-01 | 2003-09-02 | Baker Hughes Incorporated | Downhole flow control devices |
US6308783B2 (en) | 1996-04-26 | 2001-10-30 | Schlumberger Technology Corporation | Wellbore flow control device |
US5896928A (en) | 1996-07-01 | 1999-04-27 | Baker Hughes Incorporated | Flow restriction device for use in producing wells |
US6041857A (en) | 1997-02-14 | 2000-03-28 | Baker Hughes Incorporated | Motor drive actuator for downhole flow control devices |
US6070670A (en) | 1997-05-01 | 2000-06-06 | Weatherford/Lamb, Inc. | Movement control system for wellbore apparatus and method of controlling a wellbore tool |
US6112816A (en) | 1997-07-10 | 2000-09-05 | Camco International Inc. | Single-phase annulus-operated sliding sleeve |
US5979558A (en) | 1997-07-21 | 1999-11-09 | Bouldin; Brett Wayne | Variable choke for use in a subterranean well |
US6082458A (en) | 1997-07-21 | 2000-07-04 | Halliburton Energy Services, Inc. | Flow control apparatus with specific latching means for use in a subterranean well and associated methods |
US5957207A (en) | 1997-07-21 | 1999-09-28 | Halliburton Energy Services, Inc. | Flow control apparatus for use in a subterranean well and associated methods |
US5957208A (en) | 1997-07-21 | 1999-09-28 | Halliburton Energy Services, Inc. | Flow control apparatus |
EP0893575A2 (en) | 1997-07-21 | 1999-01-27 | Halliburton Energy Services, Inc. | Flow control apparatus for use in a subterranean well and associated methods |
US6044908A (en) | 1998-05-29 | 2000-04-04 | Grant Prideco, Inc. | Sliding sleeve valve and seal ring for use therein |
US6516888B1 (en) | 1998-06-05 | 2003-02-11 | Triangle Equipment As | Device and method for regulating fluid flow in a well |
US6293344B1 (en) | 1998-07-29 | 2001-09-25 | Schlumberger Technology Corporation | Retainer valve |
US6276458B1 (en) | 1999-02-01 | 2001-08-21 | Schlumberger Technology Corporation | Apparatus and method for controlling fluid flow |
US6328112B1 (en) | 1999-02-01 | 2001-12-11 | Schlumberger Technology Corp | Valves for use in wells |
US6253850B1 (en) | 1999-02-24 | 2001-07-03 | Shell Oil Company | Selective zonal isolation within a slotted liner |
US6434651B1 (en) | 1999-03-01 | 2002-08-13 | Sun Microsystems, Inc. | Method and apparatus for suppressing interrupts in a high-speed network environment |
US6338385B1 (en) | 1999-04-16 | 2002-01-15 | Hydril Company | Retrievable downhole adjustable choke |
US6328729B1 (en) | 1999-04-27 | 2001-12-11 | General Surgical Innovations, Inc. | Colporrhaphy method and apparatus |
WO2000075484A1 (en) | 1999-06-03 | 2000-12-14 | Schlumberger Technology Corporation | Apparatus and method for controlling fluid flow in a wellbore |
US6189619B1 (en) | 1999-06-07 | 2001-02-20 | Mark L. Wyatt | Sliding sleeve assembly for subsurface flow control |
WO2000079094A1 (en) | 1999-06-24 | 2000-12-28 | Baker Hughes Incorporated | Variable downhole choke |
US6371208B1 (en) | 1999-06-24 | 2002-04-16 | Baker Hughes Incorporated | Variable downhole choke |
US6513599B1 (en) | 1999-08-09 | 2003-02-04 | Schlumberger Technology Corporation | Thru-tubing sand control method and apparatus |
US6966380B2 (en) | 1999-09-24 | 2005-11-22 | Schlumberger Technology Corporation | Valves for use in wells |
US6973974B2 (en) | 1999-09-24 | 2005-12-13 | Schlumberger Technology Corporation | Valves for use in wells |
US20040108116A1 (en) | 1999-09-24 | 2004-06-10 | Mcloughlin Eugene P. | Valves for use in wells |
US6668935B1 (en) | 1999-09-24 | 2003-12-30 | Schlumberger Technology Corporation | Valve for use in wells |
WO2001021935A1 (en) | 1999-09-24 | 2001-03-29 | Schlumberger Technology Corporation | Valve for use in wells |
US6446729B1 (en) | 1999-10-18 | 2002-09-10 | Schlumberger Technology Corporation | Sand control method and apparatus |
US6450225B2 (en) | 1999-12-22 | 2002-09-17 | Sumitomo Rubber Industries, Ltd. | Noise damper for pneumatic tire |
US6318729B1 (en) | 2000-01-21 | 2001-11-20 | Greene, Tweed Of Delaware, Inc. | Seal assembly with thermal expansion restricter |
US6869063B2 (en) | 2000-04-28 | 2005-03-22 | Triangle Equipment As | Sleeve valve and method for its assembly |
WO2002016730A1 (en) | 2000-08-17 | 2002-02-28 | Abb Offshore Systems Limited | Flow control device |
US6494265B2 (en) | 2000-08-17 | 2002-12-17 | Abb Offshore Systems Limited | Flow control device |
US6422317B1 (en) | 2000-09-05 | 2002-07-23 | Halliburton Energy Services, Inc. | Flow control apparatus and method for use of the same |
US20040041120A1 (en) | 2000-12-04 | 2004-03-04 | Haughom Per Olav | Sleeve valve for controlling fluid flow between a hydrocarbon reservoir and tubing in a well and method for the assembly of a sleeve valve |
US6880638B2 (en) | 2000-12-04 | 2005-04-19 | Triangle Equipment Ag | Device for an opening in an outer sleeve of a sleeve valve and a method for the assembly of a sleeve valve |
US6715557B2 (en) | 2001-03-14 | 2004-04-06 | Schlumberger Technology Corporation | Tool string |
US6575243B2 (en) | 2001-04-16 | 2003-06-10 | Schlumberger Technology Corporation | Zonal isolation tool with same trip pressure test |
US20030056951A1 (en) | 2001-09-24 | 2003-03-27 | Frank Kaszuba | Sliding sleeve valve |
US20030159832A1 (en) | 2002-02-25 | 2003-08-28 | Williamson Jimmie Robert | Infinitely variable control valve apparatus and method |
US6715558B2 (en) | 2002-02-25 | 2004-04-06 | Halliburton Energy Services, Inc. | Infinitely variable control valve apparatus and method |
US6722439B2 (en) | 2002-03-26 | 2004-04-20 | Baker Hughes Incorporated | Multi-positioned sliding sleeve valve |
US6860330B2 (en) | 2002-12-17 | 2005-03-01 | Weatherford/Lamb Inc. | Choke valve assembly for downhole flow control |
US20040129431A1 (en) | 2003-01-02 | 2004-07-08 | Stephen Jackson | Multi-pressure regulating valve system for expander |
US7363981B2 (en) | 2003-12-30 | 2008-04-29 | Weatherford/Lamb, Inc. | Seal stack for sliding sleeve |
US20050263279A1 (en) | 2004-06-01 | 2005-12-01 | Baker Hughes Incorporated | Pressure monitoring of control lines for tool position feedback |
WO2006120466A2 (en) | 2005-05-13 | 2006-11-16 | Petrowell Limited | Apparatus for controlling a downhole device |
US7258323B2 (en) | 2005-06-15 | 2007-08-21 | Schlumberger Technology Corporation | Variable radial flow rate control system |
US7377327B2 (en) | 2005-07-14 | 2008-05-27 | Weatherford/Lamb, Inc. | Variable choke valve |
US20090277642A1 (en) | 2006-08-03 | 2009-11-12 | Welldynamics, Inc | Metal to metal seal for downhole tools |
US7823633B2 (en) * | 2007-10-09 | 2010-11-02 | Mark David Hartwell | Valve apparatus |
US20090159290A1 (en) | 2007-12-19 | 2009-06-25 | Lauderdale Donald P | Controller for a Hydraulically Operated Downhole Tool |
Non-Patent Citations (7)
Title |
---|
Examiner's First Report in counterpart Australian Appl. No. 2010243081, dated Mar. 2, 2012. |
First Office Action in counterpart Canadian Appl. No. 2721545, dated Jan. 3, 2013. |
International Search Report for PCT/GB2006/001750, dated Nov. 15, 2006. |
Omega Completion Technology "Selective Choke Valve," obtained from http://www.omega-completion.com, (c) 2009, REV 002: 26/08/09, 2 pages. |
Petrowell, "Advanced Reservoir Control (ARC) Hydraulic Sleeve," obtained from http://www.petrowell.co.uk/, undated. |
Weatherford, "Advanced Reservoir Controlled (ARC) Sleeve," obtained from www.weatherford.com, (c) 2009, 2 pages. |
Weatherford, "WXO and WXA Standard Sliding Sleeves," obtained from www.weatherford.com, (c) 2007-2008, 2 pages. |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10597977B2 (en) | 2015-09-29 | 2020-03-24 | Halliburton Energy Services, Inc. | Closing sleeve assembly with ported sleeve |
Also Published As
Publication number | Publication date |
---|---|
AU2010243081B2 (en) | 2013-03-21 |
AU2010243081A1 (en) | 2012-05-10 |
EP2447466A2 (en) | 2012-05-02 |
US20120097386A1 (en) | 2012-04-26 |
CA2721545C (en) | 2015-12-29 |
EP2447466B1 (en) | 2018-10-31 |
CA2721545A1 (en) | 2012-04-26 |
EP2447466A3 (en) | 2017-03-15 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US8657010B2 (en) | Downhole flow device with erosion resistant and pressure assisted metal seal | |
US20190136665A1 (en) | Downhole sub with hydraulically actuable sleeve valve | |
US9255466B2 (en) | Liner hanger fluid diverter tool and related methods | |
DK2994608T3 (en) | Method and apparatus for restricting fluid flow in a downhole tool | |
US20090014185A1 (en) | Incremental annular choke | |
EP3837426B1 (en) | Downhole tubular sleeve valve and use of such a sleeve valve | |
CN110603369A (en) | Up and down fracturing system and method | |
US10125570B2 (en) | Valve assembly | |
US10435987B2 (en) | Flow control valve | |
US20170335656A1 (en) | Controlled opening valve | |
CN113383144A (en) | Annular barrier with valve system | |
US7708074B2 (en) | Downhole valve for preventing zonal cross-flow | |
US10077631B2 (en) | Pressure equalizing valve insensitive to setting depth and tubing pressure differentials | |
NO20200493A1 (en) | Downhole apparatus | |
US10260654B2 (en) | Valve assembly | |
CN106460485B (en) | Downhole flow control device | |
EP2971477B1 (en) | Resettable ball seat for hydraulically actuating tools | |
US9896907B2 (en) | Equalizer valve with opposed seals biased toward closed from rising pressure on either of opposed sides | |
WO2021150592A1 (en) | Flow control valve with erosion protection | |
WO2016106099A1 (en) | Valve assembly | |
WO2016106097A1 (en) | Valve assembly |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: WEATHERFORD/LAMB, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:WARD, RYAN;WILLAMS, RON;SMITH, RODDIE;REEL/FRAME:025195/0395 Effective date: 20101021 |
|
STCF | Information on status: patent grant |
Free format text: PATENTED CASE |
|
AS | Assignment |
Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:WEATHERFORD/LAMB, INC.;REEL/FRAME:034526/0272 Effective date: 20140901 |
|
FPAY | Fee payment |
Year of fee payment: 4 |
|
AS | Assignment |
Owner name: WELLS FARGO BANK NATIONAL ASSOCIATION AS AGENT, TEXAS Free format text: SECURITY INTEREST;ASSIGNORS:WEATHERFORD TECHNOLOGY HOLDINGS LLC;WEATHERFORD NETHERLANDS B.V.;WEATHERFORD NORGE AS;AND OTHERS;REEL/FRAME:051891/0089 Effective date: 20191213 |
|
AS | Assignment |
Owner name: DEUTSCHE BANK TRUST COMPANY AMERICAS, AS ADMINISTR Free format text: SECURITY INTEREST;ASSIGNORS:WEATHERFORD TECHNOLOGY HOLDINGS, LLC;WEATHERFORD NETHERLANDS B.V.;WEATHERFORD NORGE AS;AND OTHERS;REEL/FRAME:051419/0140 Effective date: 20191213 Owner name: DEUTSCHE BANK TRUST COMPANY AMERICAS, AS ADMINISTRATIVE AGENT, NEW YORK Free format text: SECURITY INTEREST;ASSIGNORS:WEATHERFORD TECHNOLOGY HOLDINGS, LLC;WEATHERFORD NETHERLANDS B.V.;WEATHERFORD NORGE AS;AND OTHERS;REEL/FRAME:051419/0140 Effective date: 20191213 |
|
AS | Assignment |
Owner name: HIGH PRESSURE INTEGRITY, INC., TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD U.K. LIMITED, TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD NORGE AS, TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD CANADA LTD., TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD NETHERLANDS B.V., TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: PRECISION ENERGY SERVICES ULC, TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: PRECISION ENERGY SERVICES, INC., TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD SWITZERLAND TRADING AND DEVELOPMENT GMBH, TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC, TEXAS Free format text: RELEASE BY SECURED PARTY;ASSIGNOR:WELLS FARGO BANK, NATIONAL ASSOCIATION;REEL/FRAME:053838/0323 Effective date: 20200828 Owner name: WILMINGTON TRUST, NATIONAL ASSOCIATION, MINNESOTA Free format text: SECURITY INTEREST;ASSIGNORS:WEATHERFORD TECHNOLOGY HOLDINGS, LLC;WEATHERFORD NETHERLANDS B.V.;WEATHERFORD NORGE AS;AND OTHERS;REEL/FRAME:054288/0302 Effective date: 20200828 |
|
FEPP | Fee payment procedure |
Free format text: MAINTENANCE FEE REMINDER MAILED (ORIGINAL EVENT CODE: REM.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
LAPS | Lapse for failure to pay maintenance fees |
Free format text: PATENT EXPIRED FOR FAILURE TO PAY MAINTENANCE FEES (ORIGINAL EVENT CODE: EXP.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
STCH | Information on status: patent discontinuation |
Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362 |
|
FP | Lapsed due to failure to pay maintenance fee |
Effective date: 20220225 |
|
AS | Assignment |
Owner name: WELLS FARGO BANK, NATIONAL ASSOCIATION, NORTH CAROLINA Free format text: PATENT SECURITY INTEREST ASSIGNMENT AGREEMENT;ASSIGNOR:DEUTSCHE BANK TRUST COMPANY AMERICAS;REEL/FRAME:063470/0629 Effective date: 20230131 |